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Collaborating Authors
Facilities Design, Construction and Operation
Abstract There has never been a more challenging time for the energy industry. In the subsea sector, the search for optimised costs, minimized carbon emissions, and maximized performance is set to intensify as oil prices continue their unpredictable trajectory. At the same time, the risks to equipment, to people, to the local terrain and seascape will remain. What the industry needs in the face of all this is cost certainty and reduced CO2 output, derived not just from technical certainty but also execution certainty. With these concerns front of mind, it is no surprise that research into the performance of subsea equipment and service suppliers published by [1] Kimberlite LLC in May 2020 showed some concern about the capability of suppliers" offerings to meet those future requirements. 45% of those surveyed said that more advances were needed in subsea trees, citing reliability, cost, lead times, and size as areas for improvement. In addition, subsea manifolds were separately cited by another 12%, as a technology area that could be advanced. As part of the goal to achieve carbon net zero status, every single aspect of subsea operations is an opportunity to drive improvement. Through the work undertaken as described in this paper to drive standardization across the industry around the world, it can be shown that even equipment like manifolds – that come with some entrenched design and operational philosophies behind them – can deliver substantial improvements to the areas that matter most such as reduction of carbon footprint.
- Health, Safety, Environment & Sustainability > Sustainability/Social Responsibility > Sustainable development (1.00)
- Health, Safety, Environment & Sustainability > Environment > Climate change (1.00)
- Facilities Design, Construction and Operation > Offshore Facilities and Subsea Systems (1.00)
The Achievement of Resource Optimisation on Lean Remote Wellhead Platform Visit with Collaborative 52 Weeks Plan
Zar Soe, Thin (PTTEP International Ltd.) | Leelaratsameephanit, Anucha (PTTEP) | Jitputti, Phanuwat (PTTEP) | Charoensook, Sayan (PTTEP) | Rodthip, Alongkorn (PTTEP) | Chitkla, Sathit (PTTEP) | On-Dam, Apichai (PTTEP) | Sirijitt, Perapon (PTTEP)
Abstract To survive in oil and gas industry, Operating Expenditure (OPEX) must be well controlled for profit maximization. One of the most resource-utilizing activities in Zawtika offshore field is remote wellhead platform (WHP) visit which was previously bi-weekly for operations activities, maintenance activities such as preventive maintenance (PM), etc., inspection activities like flowline erosion monitoring and wells annulus pressure monitoring, thereby high Marine Gas Oil (MGO) consumption due to vessel trips/routes and increased in manpower utilization. Currently, Zawtika Offshore field has a main platform called Zawtika Processing and Living Quarter Platform (ZPQ) and 10 remote wellhead platforms (WHPs). When it is considered for future, there will be more remote wellhead platforms (WHPs) which will increase more OPEX for new phases. To tackle this, this paper describes that Myanmar Asset Zawtika launched a LEAN (Lean Six Sigma) initiative based on safely and cost-effectively reducing the frequency of remote wellhead platforms (WHP) visits, using collaborative 52 week planning to lessen OPEX cost from MGO consumption and manpower requirements as well as maintaining Zawtika Reliability and Asset Integrity (RAI) with the view of achieving resource optimization. This paper also illustrates the effective planning process across multiple functions/disciplines within different sessions/departments and at various locations called 52 weeks plan incorporating with "Integrated Operation Plan (IOP)" guideline established for the first time for Zawtika offshore field to help optimize the resources and activities plan of individual field or asset by ensuring the safety while sustaining the integrity. This paper also outlines the reduction in Greenhouse Gas (GHG) calculated back from MGO reduction which is one of PTTEP strategies for Sustainable Development (SD).
- Asia > Myanmar (0.37)
- Asia > Middle East > Israel > Mediterranean Sea (0.25)
- Well Completion > Completion Installation and Operations (1.00)
- Facilities Design, Construction and Operation (1.00)
- Data Science & Engineering Analytics > Information Management and Systems (1.00)
- (2 more...)
Assessment on Deformed Pipeline Using Integrated Metal Magnetic Memory i-MMM Technology
Raja Ismail, Raja Zahirudin (Petronas Carigali Sdn. Bhd.) | Zain, Zahrin (Petronas Carigali Sdn. Bhd.) | Che Kamaruddin, Mohd Noor Baharin (MR Technology Sdn. Bhd) | Mod Yunoh, Mohd Faridz (MR Technology Sdn. Bhd)
Abstract This paper aims to share a new concept of assets condition assessment knows as Integrated Metal Magnetic Memory (i-MMM) which integrates capability of various Non-Destructive Testing (NDT) technology in determining the current state of deformed pipeline due to external loadings. MMM technology is one of NDT technique which can be used for early failure detection especially for Stress Concentration Zones (SCZ), microcrack and fatigue damage for ferromagnetic components. MMM is a passive technology tools that relies on the measurement of Self-magnetic Leakage Field (SMLF) of the ferromagnetic materials. Most of the traditional NDT method able to inspect the macro defect but incapable to identify micro defect due to the stress concentration zone. Based on this, MMM can be integrated and complimentary in its capability to other well-known NDT testing such as Ultrasonic Testing (UT) and Hardness Test. A case study presented whereby iMMM can be utilized to determined location which are prone to deformation due to stress and detailed assessment from changes of hardness up to development of macro size defect. Based on the findings in the case study, 2 microcrack were found at 2 inspected location of the pipeline. Finally, based on the results and findings from the integrated approach of i-MMM, it can contribute and provide more impact on the simulation analysis by providing focused anomaly area or location and reduced the processing time.
- Facilities Design, Construction and Operation > Pipelines, Flowlines and Risers (1.00)
- Data Science & Engineering Analytics > Information Management and Systems (0.88)
Abstract OTC-28901-MS proposed the novel dynamically installed "fish" anchor in 2018, adopting a geometry taken from nature, for potential economic and safer tethering of floating facilities in deep water. Every cross section of the fish anchor shaft is elliptical, leading to very low drag resistance during free fall through the water column, and also low resistance in penetrating the seabed sediments. The padeye is fitted on the widest part of the shaft to mobilise the maximum resistance area under operational loading. The fish anchor embedment depth during dynamic installation, and capacity under both monotonic and cyclic operational loading in calcareous silt were assessed through centrifuge model tests and large deformation finite element analyses. During dynamic installation, the normalised tip embedment depth of the fish anchor was typically three times that for the torpedo anchors and 50% greater than that for the OMNI-Max anchors. Under operational loading, the fish anchor dove deeper, reaching penetrations 20 to 60% greater than achieved during installation. By contrast the torpedo anchors (for all mooring mudline inclinations) and the OMNI-Max anchors (apart from a single test with mooring mudline inclination of 0°) pulled out directly without diving, reflecting insufficient free-fall penetration in calcareous soil. This paper provides a follow up reporting the performance of the fish anchor through field tests in the Swan River, Perth. A 1/15 scale model fish anchor was fabricated with dry weight being 0.304 kN. The anchor was tested at five different locations. At two shallow water locations (water depths 1.1 and 1.9 m, respectively), the tests were performed from the Burswood and Maylands jetty. At relatively deeper water depths of 2.91∼4.73 m, the tests were performed from a barge. The riverbed soils consisted of clay, silty clay, silt and sandy silt. The impact velocities were 5.9∼11.7 m/s. The normalised tip embedment depths were even greater compared to those achieved from centrifuge tests in calcareous silt. Under operational monotonic loadings, the fish anchor dove, as opposed to pull out of the riverbed, for mooring angles ≤ 37∼47°. Interestingly, in contrast to non-diving torpedo and suction caisson anchors, the diving fish anchor resulted non-elliptical failure envelopes, which have been expressed mathematically. The ultimate capacity was 3.5∼15 times the weight of the anchor submerged in water for taught and catenary moorings.
Remediation of A Complex Blockage for Gumusut-Kakap Subsea Flexible Flowline from a System Perspective
Gwee, Yong Chin (Sabah Shell Petroleum Co Ltd) | Chin, Grace (Sabah Shell Petroleum Co Ltd) | Chan, Chee Hou (Sabah Shell Petroleum Co Ltd) | Chua, Lee San (Sabah Shell Petroleum Co Ltd) | Ling, Jason (Sabah Shell Petroleum Co Ltd) | Wu, Yvonne (Sabah Shell Petroleum Co Ltd)
Abstract A subsea production flexible flowline in Gumusut-Kakap field was found blocked in March 2021 during a routine production well-flowline switching/alignment operation. Further evaluation showed that the blockage was caused by the formation of hydrate and gel over the 1.3km length of the flexible flowline, as the live crude and water were left stagnant and untreated in the flowline over a prolonged period. This paper covers the remediation strategy and the associated challenges from a System perspective, which successfully unblocked the flowline within a relatively short period of time. The condition of the blockage in the flexible flowline was simulated using a commercial multiphase dynamic software to ascertain the phase distribution and hence allowed the estimation of the location and length of hydrate, gel, and emulsion in the flowline which has a downward inclination of circa 50 meters height. Heating (from production well), methanol (MeOH) soaking and flowline depressurization were planned and executed. In addition to the technical methodology, the System-wide aspects were also considered for the effective and optimum execution of the remediation activities which include attempting to fulfill the production commitment, abide by the subsea hardware and flexible flowline integrity envelope, and consider the impact of the remediation operation on other operations at the Gumusut-Kakap installation. The MeOH soaking, flowline depressurization and pressurization successfully remediated the blockage over the period of weeks. Positive results were observed at the start of the remediation when the targeted location for MeOH contact and depressurization were identified via field trial. One of the key challenges is the time factor in which to ascertain the "appropriate" waiting time for the flowline depressurization, as the remediation involved partial shut-in of the prolific production wells. A holistic System engineering approach is critical to the successful remediation of the blockage, integrating the key technical requirements as well as the soft and non-technical aspects to deliver optimum and net positive value for the asset.
- Asia > Malaysia > Sabah > South China Sea > Sarawak Basin > Baram Delta Province > Block K > Kakap Field (0.99)
- Asia > Malaysia > Sabah > South China Sea > Sarawak Basin > Baram Delta Province > Block K > Gumusut Field (0.99)
- Asia > Malaysia > Sabah > South China Sea > Sarawak Basin > Baram Delta Province > Block J > Kakap Field (0.99)
- Asia > Malaysia > Sabah > South China Sea > Sarawak Basin > Baram Delta Province > Block J > Gumusut Field (0.99)
- Health, Safety, Environment & Sustainability > Environment > Remediation and land reclamation (1.00)
- Facilities Design, Construction and Operation > Pipelines, Flowlines and Risers (1.00)
Synthesis of Zeolites from Production Sand Waste: The Circular Model for Oil and Gas Exploration and Production
Watcharasing, Sunisa (PTT Exploration and Production Public Company Limited) | Wattanakit, Chularat (Vidyasirimedhi Institute of Science and Technology) | Salakhum, Saros (Vidyasirimedhi Institute of Science and Technology) | Prasertsab, Anittha (Vidyasirimedhi Institute of Science and Technology) | Kiattikomol, Prapoj (PTT Exploration and Production Public Company Limited)
Abstract This project aims to convert production sand waste from oil & gas exploration & production process to be high value silica-based product, Zeolites, and explore opportunities to lower amount of sand waste disposal to landfill. This is one key item in Circular Model for Oil & Gas Exploration & Production. Zeolites is a microporous crystalline aluminosilicate material, which possess a superior characteristic in terms of high surface area. Therefore, it is widely utilized in many industries such as adsorbent, ion exchange, and catalysts in oil refining and petrochemical industry. In this work, various types of zeolites were synthesized from PTTEP production sand waste, to prove concept of turning sand waste to high value-added product, called zeolite. In normal operation, sand waste was sent to dispose as landfill about 50 Ton/annual. To synthesize zeolite from sand waste, there are three main steps, which are 1) Sand Pretreatment, 2) Silica Extraction, and 3) Zeolite Synthesis. Firstly, sand waste from petroleum production were pretreated by water and acid washing. Then, nanosilica was extracted out from pretreated sand by boiling the pretreated sand in NaOH solution at temperature 150 C for 4 hrs, then precipitate them to get the nanosilica substances. It was further used as a reactant source for zeolite synthesis. In the last step, the extracted silica was reacted with Structure Directing Agent (SDA); zeolite template, under optimal condition of hydrothermal treatment process to obtain zeolites product. Zeolites synthesis from production sand waste was firstly initiated and successfully achieved in lab phase, to prove of concept for extracting silica source as a substance for zeolite synthesis. Various types of zeolites (Silicalite-1, ZSM-5, Faujasite (FAU), Mordenite, and Zeolite A) can be synthesized from PTTEP sand waste with synthesis yield 80%, 68%, 85%, 40%, and 81%, respectively. This indicates that silica source from production sand waste can be utilized as a reactant source for zeolites synthesis. The next phase of prototype unit is under design phase, to allow unit can be operated more versatile, and automatically run. From this novel technology, it is expected to reduce an amount of production sand waste disposal out from separator to landfill about 50 Ton/year. The synthesized zeolites from prototype phase will be further applied in many potential applications such as an adsorbent in wastewater treatment process, as catalyst, and moisture adsorbent in oil & gas dehydration unit. New findings and requirements discovered during the prototype test will be used to iteratively optimize and improve the design of the sand to zeolites process for future industrial-scale implementation.
- Water & Waste Management (1.00)
- Materials > Chemicals > Commodity Chemicals > Petrochemicals (1.00)
- Energy > Oil & Gas > Upstream (1.00)
- Government > Regional Government > Asia Government > Thailand Government (0.76)
- Production and Well Operations (0.89)
- Health, Safety, Environment & Sustainability > Environment > Waste management (0.55)
- Facilities Design, Construction and Operation > Processing Systems and Design > Dehydration (0.54)
- Management > Strategic Planning and Management > Exploration and appraisal strategies (0.40)
Abstract The Magnetic Tomography Method (MTM) has been introduced as a non-intrusive inspection technique capable of inspecting ferromagnetic materials such as carbon steel pipeline without any contact. A buried main pipeline in one of PETRONAS's operating countries that had been out of service for more than 8 years needed to be inspected prior to being re-instated. This paper discusses in detail how this innovative MTM technology was used to successfully inspect a decommissioned buried pipeline and safely re-instated the pipeline operation. The MTM inspection covered 172 kilometres of buried pipeline, including the calibration work which involved direct assessment methods. The danger degrees such as Rank 1, 2 and 3, as well as the safe operating pressures, Psafe along the entire pipeline were determined using the MTM results of Risk Factor F in accordance with MTM technical approach. Direct assessment findings were consistent with the MTM inspection findings, as the technology detected all of the anomalies discovered by the direct assessment methods. MTM inspections of decommissioned buried pipelines are proven since they are reliant on the residual self-magnetic leakage field (SMLF) in the pipeline and do not require any intrusive works. Being a non-intrusive inspection method, this technology was not affected by the low pressure & low flowrate, and no changes to the pipeline operation mode was required during the inspection. Further, this MTM inspection method was not affected by the stalled pigs inside the pipeline, as this inspection method was non-intrusive. The inspection results serve as major input to the Pipeline Integrity Management System (PIMS) to effectively manage the integrity and risk level of the pipeline.
- Well Completion > Well Integrity > Subsurface corrosion (tubing, casing, completion equipment, conductor) (1.00)
- Facilities Design, Construction and Operation > Pipelines, Flowlines and Risers > Piping design and simulation (1.00)
- Facilities Design, Construction and Operation > Pipelines, Flowlines and Risers > Materials and corrosion (1.00)
Abstract It is widely accepted that live crude oil samples provide the most field representative fluids when investigating asphaltenes and paraffin wax problems in laboratory testing. However, this approach is limited by availability of live samples and the potential that samples collected during drilling will be insufficiently representative due to contamination. This paper demonstrates that re-livened oil comprising dead oil and just 1 or 2 solvents can be an acceptable replacement where live oil of sufficient quality is not available. We outline a best-of-both approach: using readily available dead oil but replacing the volatile ends with components that reproduce much of the solvating and phase behaviour of live oil, and where they differ from it, they do so in a predictable manner, which can be readily modelled using an equation of state (EoS) simulator. This avoids the expense and time required to restore the oil to a precise replica of live fluid while still generating laboratory data to increase confidence in predictions for the actual live oil composition generated by the EoS software. Illustrative examples are given to demonstrate different ways in which re-livened oil can be designed to mimic key features of live oil behaviour, and any differences can be modelled. Wax appearance measurements were made for re-livened oil and used to calibrate an EoS model. When used to simulate data for a live oil, the calibrated model gave excellent agreement with field data. Subsequently, deposition tests were carried out with re-livened oil and used to qualify a wax inhibitor for subsea application. Measurement of the Asphaltenes Onset Pressure (AOP) for re-livened oil was used to tune the EoS model for the analogous live oil, yielding predictions of the asphaltenes precipitation envelope (APE) that were consistent with those obtained using the live oil. This illustrates that live oil may not always be necessary to obtain a reliable APE, especially when the only live oil samples are of questionable quality. Solubility theory was applied to the selection of conditions for asphaltenes flow-loop deposition, wherein a precipitant is added to dead oil to induce deposition. This approach can determine both the identity and correct proportion of a suitable precipitant to simulate conditions close to the bubble point where deposition commonly occurs. Our work shows how experimental results (both laboratory and field) were used to validate the methodology presented here. The findings of our work will lead to significant cost-savings in performing both flow assurance risk assessments and inhibitor qualification. Rather than going to the significant expense and operational difficulty and risk of collecting and transporting live samples, such screenings can be performed on re-livened fluids that are both field representative and cost-effective.
- Energy > Oil & Gas > Upstream (1.00)
- Materials > Chemicals > Commodity Chemicals > Petrochemicals (0.51)
Abstract Objectives/Scope In the current situation of the industry, high numbers of prospects are being considered as not economical to develop due to various factors including low reserves, high complexity and stranded locations with no suitable host facility to tie-in to nearby. This paper will discuss how the utilization of direct-hydraulic subsea control technology, when coupled with shallow water tree technology, can be deployed to enable technically and commercially viable solutions for marginal shallow water fields. Methods, Procedures, Process Under these circumstances, direct hydraulic technology has a number of advantages over traditional EH-MUX control systems, such that direct hydraulics can enable the development of fields which would otherwise be uneconomical. These advantages include – Reduced topside equipment complexity, leading to cost reductions Reduced system complexity, therefore enabling the project to progress directly from Conceptual Engineering stage to Detailed Design, using a ‘Vendor Led Solution’, thereby reducing or eliminating FEED stage. Reduced topside equipment weights and dimensions, enabling brownfield tie-in to existing ‘minimal facility’ host, such as Light Weight Structure or Tarpon. Reduced electrical equipment, thereby reducing required modifications to host facility. Reduced electrical power requirements, enabling the system to be powered by use of renewable energy sources such as wind power or solar power. Suitable for remote operations and therefore suitable for unmanned facilities. Results, Observations, Conclusions By using Direct Hydraulic technology, the project was able to achieve a commercially attractive and technically fit-for-purpose design, leading to successful project sanction (the first such project in Malaysian waters), and opening the door for similar future developments to follow. Novel/Additive Information This paper will present information and methods that will be of benefit to other Operators in the subsea industry who are seeking to unlock reserves that are currently in marginal fields and would be uneconomical to develop using other methods. The benefits that can be gained are both in terms of proof of concept using off-the-shelf designs, and opening up otherwise uneconomical fields for development. In this particular case, the project opens up a further 6 new fields which were previously considered uneconomic to develop.
- Health, Safety, Environment & Sustainability (1.00)
- Facilities Design, Construction and Operation > Offshore Facilities and Subsea Systems > Controls and umbilicals (1.00)
A Risk Based Approach for the Integrity Management of Single Point Mooring Systems
Isnadi, Biramarta (PETRONAS Carigali Sdn. Bhd.) | Mahasan, Suhaimi (PETRONAS Carigali Sdn. Bhd.) | Omar, Syahnaz (PETRONAS Carigali Sdn. Bhd.) | Fazli, W Hariz (PETRONAS Carigali Sdn. Bhd.) | Sahari, Yusuf (PETRONAS Carigali Sdn. Bhd.) | Suhendra, Ave (PETRONAS Carigali Sdn. Bhd.) | Wong, Ellis (PETRONAS Carigali Sdn. Bhd.) | Kamaruzaman, Aiman (PETRONAS Carigali Sdn. Bhd.) | Khan, Riaz (PETRONAS Carigali Sdn. Bhd.)
Abstract This paper describes the SPM Integrity Management approach using risk based strategies for Single Point Mooring (SPM) throughout its asset life cycle, to ensure that there is a structural integrity management processes are implemented and SPM asset fitness for purpose is always maintained. SPM is one of the most important assets for any oil and gas upstream business, as its primary function is for product export and offloading operations. PETRONAS UPSTREAM currently operate seven (7) Single Point Mooring (SPM) assets for its Malaysia Upstream/ Downstream. To manage the integrity of the SPMs, an Integrity Management system has been developed and includes newer assets and those that are approaching or exceeding design lives. To optimize and focus limited resources toward critical activities, a SPM risk-based strategy and methodology for the SPM assets has been developed. The risk based inspection approach is aligned with the Structural Integrity Management (SIM) processes of DATA, EVALUATION, STRATEGY PROGRAM of the API RP2SIM code of practice. A qualitative risk based integrity management has been developed and for its implementation, inspection and maintenance activities shall target high expenditure items. SPM design, characteristic, assessment, and inspection data have been compiled and utilized in the risk based approach development. With this risk-based approach, PETRONAS can optimize and significantly reduce its inspection and maintenance activities whilst keeping operational risk levels within acceptable limits. The risk-based approach provides that added advantage to look at inspections and maintenance activities critically and make informed decisions on resourcing and aligning inspection & maintenance campaigns for the future. Inspection and maintenance measures also include an anomaly management, RBI, data management and inspections scopes of work which are being digitized and maintained within the Company's Structural Integrity Compliance System (SICS).
- Energy > Oil & Gas > Upstream (1.00)
- Government > Regional Government > Asia Government > Malaysia Government (0.58)
- Well Drilling > Wellbore Design > Wellbore integrity (1.00)
- Management (1.00)
- Facilities Design, Construction and Operation > Offshore Facilities and Subsea Systems > Mooring systems (1.00)